Control Architectures for Power Distribution Networks with Distributed Energy Resources

ABSTRACT

Architectures, apparatuses, methods, systems, and techniques for controlling electrical power distribution network are disclosed. Embodiment distributed, hierarchical controls including layered locational energy service control variables may be utilized to determine and control the provision of energy services, including real power, reactive power (VAR), and capacity reserves, by DERs in a distribution network. In a first ex-ante iteration a simulation may be performed to calculate a set of subnetwork-specific control variables based on subnetwork locational energy service prices and a plurality of sets of DER-specific control variables based on DER locational energy service prices. A second ex-ante iteration calculates a set of actual subnetwork-specific control variables based on subnetwork locational energy service prices and a plurality of sets of actual DER specific control variables based on DER locational energy service prices. Provision of energy services by DERs in a distribution network occurs in response to the determined control variables.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application is a national stage application of International Application No. PCT/US2020/016981, filed on Feb. 6, 2020, which claims priority to U.S. patent application Ser. No. 16/274,314, filed on Feb. 13, 2019 (now U.S. Pat. No. 10,903,652, issued on Jan. 26, 2021), all of which applications are hereby incorporated herein by reference.

BACKGROUND

The present application relates to control architectures for electrical power distribution networks (sometimes referred to herein as distribution networks) with distributed energy resources (DERs) and related apparatuses, methods, systems, and techniques. Electrical power transmission grid control systems have utilized locational pricing, such as locational marginal pricing, in connection with controlling operation of electrical power transmission grids. The proliferation of DERs in distribution networks offers a similar potential and some proposals have been made to extend similar controls systems to distribution networks. In practice, however, such proposals have encountered and been frustrated by a number of technological problems.

TECHNICAL FIELD

Determining locational pricing in distribution networks including DERs is very difficult because of their complexity and temporal variability. Many proposed control solutions are so computationally intensive as to be impracticable. Furthermore, even with the benefit of extraordinary computing resources, control systems for distribution networks including DERs face multiple unmet technical challenges. For example, distribution network operators may lack control authority over the operation of DERs in the distribution system making true dispatch or demand-response control infeasible. This means that even a perfectly calculated solution cannot in practice be reliably implemented. Additionally, DERs in a distribution network may be controlled by aggregators who control multiple DERs. Furthermore, aggregator-controlled DERs may be located in different locations throughout the distribution network and the constituent DERs of an aggregator will vary over time. Even the fastest, most accurate and most precise computations of locational pricing as a control variable may result in undesirable network operation such as phase imbalance, line congestion, over-voltage conditions, and other operating constraint excursions. There remains a substantial need for the unique architectures, apparatuses, methods, systems, and techniques disclosed herein.

SUMMARY

Unique architectures, apparatuses, methods, systems, and techniques for controlling electrical power distribution network are disclosed. In certain embodiments, a distributed, hierarchical control architecture including layered locational energy service control variables is utilized to determine and control the provision of energy services (e.g., real power, reactive power (VAR), and capacity reserves) by DERs in a distribution network. In exemplary embodiments, the energy service control variables may be denominated in terms of price or cost of a given energy service and may be referred to as energy service price control variable(s). Denomination of an energy service control variable in terms of price or cost is convenient and simplifies conducting related economic activity. It shall be appreciated, however, that denomination of the control variable in terms of price or cost is essentially arbitrary and does not alter the fact that the energy service control variables are technical control features used for controlling the operation of particular systems and devices such as illustrated by the examples disclosed herein. Further embodiments, forms, objects, features, advantages, aspects, and benefits shall be apparent from the following description and drawings.

BRIEF DESCRIPTION OF THE DRAWINGS

For the purposes of clearly, concisely and exactly describing illustrative embodiments of the present disclosure, the manner, and process of making and using the same, and to enable the practice, making and use of the same, reference will now be made to certain exemplary embodiments, including those illustrated in the figures, and specific language will be used to describe the same. It shall nevertheless be understood that no limitation of the scope of the invention is thereby created and that the invention includes and protects such alterations, modifications, and further applications of the exemplary embodiments as would occur to one skilled in the art.

FIGS. 1 and 2 are schematic diagrams illustrating certain physical and logical aspects of an exemplary electrical power distribution network.

FIGS. 3a and 3b are flowcharts illustrating certain aspects of an exemplary energy service control process for an electrical power distribution network.

FIG. 4 is a flowchart illustrating certain aspects of an exemplary energy service control process for an electrical power distribution network.

FIG. 5 is a schematic diagram illustrating the occurrence of multiple energy service control process and energy service control process over time.

DETAILED DESCRIPTION OF ILLUSTRATIVE EMBODIMENTS

With reference to FIGS. 1 and 2, there are illustrated certain physical and logical aspects of an exemplary electrical power network, in this exemplary embodiment an electrical power distribution network 100 (sometimes referred to herein as distribution network 100). Distribution network 100 includes a hierarchy of control layers including a top layer 110 (according to this embodiment also referred to herein as a first layer), an intermediate layer 120, a middle layer 130 (according to this embodiment also referred to herein as a second layer) and a bottom layer 140 (according to this embodiment also referred to herein as a third layer) each of which comprises certain components configured to perform certain operations as further described herein below.

According to the embodiment shown in FIG. 1, top layer 110 of distribution network 100 includes a substation 112 (sometimes referred to as a transmission or HV/HV substation) which is configured to operatively couple distribution network 100 with electrical power transmission network 10 (according to this embodiment also referred to herein as a higher layer electrical power transmission grid) and to provide bidirectional power conversion between electrical power transmission network 10 and the distribution network 100. In certain embodiments substation 112 is configured and equipped to provide high voltage/high voltage (HV/HV) power conversion although other power level conversions are also contemplated. Substation 112 includes a distribution system controller 114 (according to this embodiment also referred to herein as a first layer controller) which may be configured to control the operation of substation 112 and is configured to bi-directionally communicate with other controllers in distribution network 100. Distribution system controller 114 is, according to certain embodiments, the sole controller provided at top layer 110 of distribution network 100.

Intermediate layer 120 of distribution network 100 includes substations 122 a, 122 b (sometimes referred to as sub-transmission substations or HV/MV substations) which are configured to operatively couple top layer 110 with middle layer 130 and to provide bidirectional power conversion therebetween. In certain embodiments substations 122 a, 122 b are configured and equipped to provide high voltage/medium voltage (HV/MV) power conversion although other power level conversions are also contemplated. Substations 122 a, 122 b may include respective controllers which control their respective operation and, while not required by the present example, may also be configured to bi-directionally communicate with other controllers in distribution network 100. It is understood by the skilled person that intermediate layer 120 may not be necessary for the present example. As denoted by ellipsis 120 n, intermediate layer 120 of distribution network 100 may include a greater or lesser number of substations at intermediate layer 120. In some embodiments middle layer 120 may be omitted. Other embodiments may include additional layers including respective substations between layer 120 and layer 110 and/or between layer 120 and layer 130.

Middle layer 130 of distribution network 100 includes distribution substations 152, 162, 172 (sometimes referred to as MV/MV substations) which are configured to operatively couple intermediate layer 120 with bottom layer 140 and to provide bidirectional power conversion therebetween. In certain embodiments substations 152, 162, 172 are configured and equipped to provide medium voltage/medium voltage (MV/MV) power conversion although other power level conversions are also contemplated. Substations 152, 162, 172 include respective subnetwork controllers 154, 164, 174 (according to this embodiment also referred to herein as second layer controllers) which control their respective operation and are configured to bi-directionally communicate with other controllers in distribution network 100. As denoted by ellipsis 130 n, distribution network 100 may include may include a greater or lesser number of substations at middle layer 130.

Bottom layer 140 includes distributed energy resources (DERs) 155, 157, 167, 177 (according to this embodiment also referred to herein as third layer entities) which are operatively coupled with and configured to receive power from or provide power to certain substations 152, 162, 172 of middle layer 130. DERs 155, 157, 167, 177 may comprise, for example, engine powered generators, solar power systems, wind power systems, small hydropower systems, biomass power systems, biogas power systems, geothermal power systems, energy storage systems (ESS) such as batteries or flywheels, energy use or load curtailment systems or combinations thereof. Bottom layer 140 also includes demand response DERs (DR-DERs) 159, 169 (according to this embodiment also referred to herein also as third layer entities) which are operatively coupled with and configured to receive power from or provide power to certain substations 152, 162, 172 of middle layer 130. DR-DERs 159, 169 may comprise, or may consist only of demand response energy use or load curtailment systems. One or more of DERs 155, 157, 167, 177 may be autonomously controlled by its respective DER controller such as the higher layer control elements lack the ability to control or dictate operation of the DER. In contrast, DR-DERs, are controlled by their respective DER controller which subject to which is sometimes referred to as demand response or dispatch operation. As denoted by ellipsis 140 n, distribution network 100 may include a greater or lesser number of DERs and/or DR loads at bottom layer 140.

Middle layer 130 and bottom layer 140 of distribution network 100 include multiple distinct subnetworks 150, 160 170. In the illustrated embodiment, subnetwork 150 comprises distribution substation 152, DERs 155, 157 and DR-DER 159, subnetwork 160 comprises distribution substation 162, DER 167 and DR-DER 169, and subnetwork 170 comprises distribution substation 162 and DER 177. It shall be appreciated that this subnetwork configuration is a simple example and that subnetworks with many either more or less DERs, DR-DERs and/or additional loads or less loads are contemplated by the present disclosure.

DERs 155, 157, 167, 177 and DR-DERs 159, 169 are controlled by respective DER controllers (according to this embodiment also referred to herein as third layer controllers) which may be controllers dedicated to an individual DERs or aggregator controllers for multiple DERs. For example, DER 155 is controlled by DER controller 192 which is dedicated to that purpose. Similarly, DR-DER 159 is controlled by DER controller 194 which is dedicated to that purpose. In contrast, DER controller 196 controls DER 177 and DR-DER 169 which are in separate subnetworks. Similarly, DER controller 198 controls DER 157 and DER 176 which are also in separate subnetworks.

It shall be appreciated that distribution network 100 is one example of a distribution network including a distribution system controller at a transmission substation which couples the electrical power distribution network to an electrical power transmission grid. The distribution network is also one example of a distribution network including a plurality of subnetwork controllers provided at a respective plurality of distribution substations serviced by the transmission substation and servicing a respective plurality of subnetworks of the distribution network. Additionally, in the distribution network 100 each of the subnetwork controllers is configured to bi-directionally communicate with the distribution system controller and to bidirectionally communicate with a respective plurality of distributed energy resource controllers (DER controllers). Furthermore, each of the DER controllers is configured to control operation of one or more of the plurality of DERs, and one or more of the DER controllers is configured to control operation of two or more DERs which are located in different subnetworks of the distribution network.

It shall be further appreciated that the controllers disclosed herein including, such as distribution system controller 114, subnetwork controllers 154, 164, 174, and DER controllers 192, 194, 196, 198 may be provided in a number of forms and configurations. For example, the disclosed controllers may comprise of digital circuitry, analog circuitry, or combinations of both of these types. The processing circuitry of the disclosed controllers may be programmable, an integrated state machine, or a hybrid combination thereof. The disclosed controllers may include processing circuitry including or more arithmetic logic units, central processing units, or processor cores, as well as one or more memories, communication interfaces, sensors, and other analog or digital circuitry operatively coupled with the processing circuity. In some forms, the disclosed controllers may be microprocessor-based or microcontroller-based computing devices. Additionally, the disclosed controllers may be provided as single locations in distribution network 100. In such forms, the disclosed controllers may comprise a single microprocessor based or microcontroller-based computing device or multiple such computing devices. The disclosed controllers may also be distributed across multiple locations. In such forms, components of the disclosed controllers present at a given location of distribution network 100 may comprise a single device or multiple devices. It shall be further appreciated only a portion of the disclosed controllers need physically reside at a given location of distribution network 100 in order to be considered present at that location. Thus, for example, a subnetwork controller may include multiple controller components only some of which are present at a given distribution substation.

FIG. 3a illustrates another exemplary embodiment of the present disclosure. In this embodiment, a system for controlling operation of an electrical power network (e.g. network 100 in FIGS. 1 and 2) comprises a first layer controller, e.g. the distribution system controller 114 as in the embodiment illustrated in FIGS. 1 and 2 above or the independent system operator controller and/or a regional transmission operator controller 1000 as in the embodiment illustrated in FIG. 6 below. The first layer controller is located at a first layer 110 and is configured to couple the electrical power network to a higher layer electrical power transmission grid, e.g. the electrical power transmission network 10 above. According to this embodiment, the system further comprises second layer controllers, e.g. the subnetwork controllers 154-174 as in the embodiment illustrated in FIGS. 1 and 2 above or the distribution system controllers 1100-1300 as in the embodiment illustrated in FIG. 6 below. The second layer controllers are located at a second layer 130. According to this embodiment, the system further comprises third layer controllers, e.g. the DER-controllers 12-198 as in the embodiment illustrated in FIGS. 1 and 2 above or the subnetwork controllers 1110-1330 as in the embodiment illustrated in FIG. 6 below. The third layer controllers are located at a third layer 140 and each of the third layer controllers is configured to control at least one third layer entity, e.g. one or more of the DERs 155, 157, 167, 169, 177 as in the embodiment illustrated in FIGS. 1 and 2 above or the subnetworks as in the embodiment illustrated in FIG. 6 below. The first layer controller and the second layer controllers are configured to bi-directionally communicate which each other, and the second layer controllers and the third layer controllers are configured to bi-directionally communicate which each other. The second layer controllers are configured to control a respective subnetwork comprising at least one of the third layer controllers and the respective at least one third layer entity.

According to this embodiment, the system is configured to determine a service control variable for controlling determination and energy service request operation. This is done as follows:

In step S100, the second layer controllers determine and transmit to the first layer controller aggregate energy service forecasts for their respective subnetworks determined based upon third layer entity energy service forecasts provided by the respective at least one third layer controller in each subnetwork.

In step S102, the first layer controller determines and transmits to each of the second layer controllers respective second layer controller-specific energy service forecasts determined in response to the aggregate energy service forecasts and a power flow optimization for the electrical power network.

In step S104, the second layer controllers determine and transmit to the respective at least one third layer controller respective third layer controller-specific energy service forecasts and energy service requests determined in response to the respective second layer controller-specific energy service forecasts.

In step S106, the second layer receives at least a portion of the energy services requested by the third layer controllers, in response to transmission of the third layer controller-specific energy service forecasts and energy service requests.

In step S108, the first layer receives at least a portion of the energy services requested by the second layer controllers.

With reference to FIG. 3b , there are illustrated certain aspects of an exemplary control process 300 for an electrical power distribution network. In one aspect, control process 300 provides one example of a distributed, hierarchical control process for a distribution network which utilizes layered locational pricing as a lever or control variable for controlling operation of a distribution network, such as distribution network 100. In another aspect, control process 300 illustrates exemplary operations in an ex-ante energy service price control variable calculation utilized in controlling operation of a distribution network, such as distribution network 100. In describing control process 300 reference is occasionally made to certain elements of distribution network 100. It shall nevertheless be appreciated both that the element of distribution network 100 may be utilized even where not specifically referenced, and that control process may be implemented in and performed by a variety of other electrical power distribution networks and components.

Control process 300 may begin with operation 302 in which a plurality of DER controllers (including both controllers for individual DERs and aggregator controllers for multiple DERs) determine DER controller-specific energy service forecasts including energy services prices and transmit the energy service forecasts to one or more respective subnetwork network controllers. In the context of distribution network 100 these operations may involve DER controllers 192, 194, 196, 198 and/or other DER controllers as well as subnetwork controllers 154, 164, 174 and/or other subnetwork controllers. The energy service forecast includes initial bid price values for one or more energy services which denote the price at which the DER or aggregator generating the forecast will provide the one or more energy service at a future time or over a future time period. In certain forms, the one or more energy services include one or more of real power, reactive power (VAR), and reserve power capacity. The DER controller-specific energy service forecasts may be based on autonomous decisions of each DER controller as to how to participate in various energy service operations. The energy service forecasts may also include linearized cost functions indicating the variation of the energy service forecast as a function of price. In the first iteration of control process 300, operation 302 may determine and transmit initial energy service forecasts including energy services prices. In the second and any subsequent iterations of control process 300, operation 302 may transmit updated energy service forecasts including energy services prices which may be determined by operation 302 or by another operation such as operation 314 described below.

Control process 300 proceeds from operation 302 to operation 304 in which each of a plurality of subnetwork controllers determines subnetwork controller-specific aggregate energy service forecasts including energy services prices for their respective subnetworks and transmits their respective aggregate energy service forecasts to a distribution network controller. Thus, operation 304 corresponds to step S100 in the embodiment illustrated in FIG. 3a . Each of a plurality of subnetwork controller determines an aggregate energy service forecast including an aggregate energy service price for its entire respective subnetwork using the energy service forecasts received from their DERs in their respective subnetwork and a model of the net electrical behavior of its respective subnetwork. The subnetwork models preferably recognize that not all DERs and loads in a given subnetwork can be controlled and that some DERs may autonomously choose not to participate in any energy service operation or in a given energy service operation. Thus, the model may distinguish between participating DERs and nonparticipating DERs or uncontrolled loads and generators in the subnetwork. The model may also account for the historical behavior of participating DERs in the subnetwork to assess the likelihood that they will participate in a given energy service operation. The aggregate energy service forecast generated by each subnetwork controller may also include an aggregate cost function based on the cost functions provided by its constituent DER controllers into a single linear function for the whole subnetwork. Once calculated, each subnetwork controller sends its aggregated energy service forecasts to a distribution system controller.

Control process 300 proceeds from operation 304 to conditions 306 which evaluates whether control process 300 is in its first iteration for a given set of control operations (e.g., a particular energy service provision event and/or a particular control period, time or window). If conditional 306 evaluates as true, i.e. the control process is in its first iteration, control process 300 proceeds to operation 308 in which the distribution network controller determines and transmits to each of the subnetwork controllers an initial network-wide energy service price determined in response to the initial aggregate energy service prices and without the use of a power flow optimization or an optimized power flow (OPF). Thus, operation 308 does not consider or adjust for power flow conditions such as phase imbalance, network congestion, over-voltage conditions or other operating constraint excursions for the distribution network.

If conditional 306 evaluates as false, i.e. the control process is not in its first iteration, control process 300 proceeds to operation 309 in which the distribution network controller determines and transmits to each of the subnetwork controllers respective subnetwork controller-specific energy service prices determined in response to the updated aggregate energy service prices and a power flow optimization or optimized power flow for the distribution network. Thus, operation 309 considers and adjusts for power flow conditions such as phase imbalance, network congestion, over-voltage conditions or other operating constraint excursions for the distribution network.

The distribution network controller may perform a power flow optimization to calculate an OPF using the forecasts and cost functions from which it derives substation controller-specific energy service prices. The power flow optimization and OPF may utilize a network model encompassing and extending only from top layer 110 to middle layer 130 or excludes elements of bottom layer 140. This mitigates the introduction of model and computational complexities that would otherwise be introduced by elements below middle layer 130.

From operation 308 or 309, control process 300 proceeds to operation 310 in which, depending on the iteration state of control process 300, the distribution network controller transmits to each of a plurality of subnetwork controllers either an initial network-wide energy service price such as determined by operation 308 or a subnetwork controller-specific energy service prices such as determined by operation 309. Thus, operations 309 and 310 correspond to step 5102 in the embodiment illustrated in FIG. 3a . It shall be appreciated that control process 300 is one example of an iterative control process for a distribution network including DERs. The first iteration of control process 300 in a given set of control operations may be considered a simulation or initialization of an energy service price control variable as the results of its calculations will not serve directly as the ultimate control variable for controlling provision of energy services or settlement of related transactions. On the other hand, the second and any subsequent iterations of control process 300 in a given set of control operations may be considered a determination of an energy service price control variable as the results of its calculations may serve directly as the ultimate control variable for generating energy service requests and controlling provision of energy services and settlement of related transactions. Furthermore, reference to a calculation of energy service price control variable shall be understood to encompass aspects of both the first iteration and subsequent iterations of control process 300.

Control process 300 proceeds from operation 310 to operation 312 in which, depending on the iteration state of control process 300, the subnetwork controllers determine and transmit to their respective DER controllers either initial DER controller-specific energy service prices determined in response to the initial network-wide energy service price (e.g., in the first iteration of control process 300) or updated DER controller-specific energy service prices and requests determined in response to the respective subnetwork controller-specific energy service prices (e.g., in the second and any subsequent iteration of control process 300). Thus, operation 312 corresponds to step 5104 in the embodiment illustrated in FIG. 3 a.

Control process 300 proceeds from operation 312 to operation 314 in which the plurality of DER controllers determines updated energy service forecasts including updated energy services prices and transmit the updated energy service forecasts to one or more respective subnetwork network controllers.

Control process 300 proceeds from operation 314 to conditional 316 which evaluates whether one or more stopping criteria has been met. In certain embodiments the stopping criteria may evaluate a limit on the total number of iterations or a limit of control process 300, for example, two iterations, three iterations or another number of iterations predetermined to allow control process 300 to complete its iterations in a time frame needed for control of the distribution network. In certain embodiments, the stopping criteria may evaluate a limit on the total iteration time of control process 300 to allow control process 300 to complete its iterations in a time frame needed for control of the distribution network. In certain embodiments, the stopping criteria may evaluate both a convergence criterion for control process 300 and a limit on the total number of iterations or total iteration time of control process 300. The convergence criterion may be, for example, a threshold for the difference or variation in the updated energy service forecasts from the DER controllers and their prior forecast iteration (either the initial forecast or a prior updated forecast).

If conditional 316 evaluates as false, control process 300 proceeds to operation 302 and from there may proceed as described above. On the other hand, if conditional 316 evaluates as true, control process 300 proceeds to operation 318 in which the subnetwork controllers send DER controller-specific energy service prices and energy service requests to the DER controllers in their respective subnetworks. Control process 300 then proceeds to operation 320 in which in response to transmission of the DER controller-specific energy service prices and energy service requests, the distribution substations receive at least a portion of the energy services requested of the DER controllers and the transmission substation ultimately receives at least a portion of the energy services requested of the subnetwork controllers. Control process 300 then proceeds to operation 322 which initiates control process 400.

With reference to FIG. 4, there are illustrated certain aspects of an exemplary ex-post control process 400 for an electrical power distribution network. It shall be appreciated that ex-post control process 400 is one example of an indirect control mechanism for providing and/or promoting compliance with energy service requests sent by subnetwork controllers to DER controllers. As indicated above, it is contemplated that a distribution network controller and subnetwork controllers may lack direct control authority over the operation of one or multiple DERs in the distribution system making true dispatch or demand-response control infeasible and resulting in undesirable system operating conditions. Ex post control process 400 addresses this technical challenge by providing indirect enforcement or quasi-dispatch control authority. As with control process 300 and the other controls and control aspects disclosed herein, that the denomination of control variables which are used to achieve these technical effects in terms of cost or price is essentially arbitrary and does not alter the fact that the disclosed apparatuses, methods, and systems are technical control system features used controlling the operation of a particular systems and devices.

In a further aspect, ex-post control process 400 illustrates exemplary operations in an ex-post energy service price control variable calculation utilized in controlling operation of a distribution network, such as distribution network 100. In another aspect, ex post control process 400 illustrates exemplary operations in an ex-post energy service price control variable calculation utilized to mitigate deviations in the response to the DERs of a distribution network to energy service requests determined in and ex-ante energy service price control variable calculation such as the example illustrated by control process 300. In describing ex-post control process 400 reference is occasionally made to certain elements of distribution network 100. It shall nevertheless be appreciated both that the element of distribution network 100 may be utilized even where not specifically referenced, and that control process may be implemented in and performed by a variety of other electrical power distribution networks and components.

Ex-post control process 400 may begin with operation 402 in which actual measurements of a distribution network, such as distribution network 100, are communicated to ex-post control logic implemented in the subnetwork controllers and the distribution network controller. The network measurements communicated to each subnetwork controllers may include real power output, reactive power output, load, real power consumption, reactive power consumption, bus voltages, and other electrical characteristics of the DERs present in its respective subnetwork. The measurements may be received from meters associated with the DERs or may be calculated by state estimation logic provided in one or more controllers of each respective subnetwork, such as the subnetwork controllers or other controllers.

Ex-post control process 400 proceeds from operation 402 to operation 404 in which the distribution network controller calculates a new set of actual subnetwork controller-specific energy service prices that reflect the actual conditions of the subnetwork during the control interval and communicates the actual subnetwork controller-specific energy service prices to each corresponding subnetwork controller. The distribution substations may be treated as aggregate loads for the purpose of this calculation. Subnetworks that backfeed power through the substation may be considered negative loads.

Ex-post control process 400 proceeds from operation 404 to operation 406 in which each subnetwork controller calculates a new set of actual DER controller-specific energy service prices that reflect the actual conditions of the DER during the control interval. For example, if a DER demands more power than anticipated causing an undervoltage condition, its updated controller-specific energy service price will reflect the impact on the network. This calculation by the subnetwork controllers is based on the actual subnetwork controller-specific energy service prices determined and communicated by the distribution network controller.

Ex-post control process 400 proceeds from operation 406 to operation 408 in which the difference between the DER-specific ex-ante energy service prices and the corresponding DER-specific ex post energy service prices are calculated and a corrective settlement is conducted.

In contrast to ex-ante control process 300, ex-post control process 400 does not require iterations between the layers of the hierarchy. Instead, a single top to bottom iteration may be performed. Alternatively, the distribution system controller may be structured to perform actual energy service price calculations for the entire distribution network, including all subnetworks and all DERs. The disclosed control architecture makes this feasible because DER energy service values are fixed as measured operating points. Thus, the ex-post calculation does not pose a complex optimization problem as would be found in the ex-ante control process.

With reference to FIG. 5, there is illustrated a timeline 500 depicting the occurrence of multiple energy service control processes over multiple interleaved control intervals 510, 520, 530. Each control interval 510, 520, 530 includes three operations: an ex-ante control process, energy service operation involving actual energy flow, and an ex post settlement control process. Thus, control interval 510 includes ex-ante control process 512, energy service operation 514, and ex-post settlement control process 516. Control interval 520 includes ex-ante control process 522, energy service operation 524, and ex-post settlement control process 526. Control interval 530 includes ex-ante control process 532, energy service operation 534, and an ex-post settlement control process which occurs outside the illustrated portion of timeline 500 as indicated by ellipsis 530 n which further indicates the potential presence of further interleaved control intervals which are not illustrated. Ex-ante control processes 512, 522, 532 may utilize one or more aspects of process 300 described above. Ex-post settlement control processes 534, 534, 534 may utilize one or more aspects of process 400 described above.

The processes of control intervals 510, 520, 530 apply to discrete but interleaved time intervals. As, illustrated, for a given interval of interest, the ex-ante step occurs before the energy service operation of the interval starts. In this step, energy service prices are calculated based on forecasts of energy service capacity and demand, and the market for services is settled based on these prices and commitments by all participants. Next, the energy service process interval of interest begins, and actual energy services are generated and used. Finally, the expost step occurs after the interval of interest ends. In the ex-post step, a new set of energy service prices are calculated based on the actual network operation measured during the interval, and market participants may be compensated or penalized at the new prices according to their performance.

In timeline 500 each energy service operation interval is a 15-minute interval. For example, actual flow of energy in energy service operation 514 occurs from 10:00 to 10:15. Prior to this, the ex-ante control process 512 is performed. In principle control process 512 may be performed at any time before energy service operation 514 occurs but is preferably perform sufficiently close to the energy service operation 514 that the forecasts are accurate, but sufficiently early to allow enough time for ex-ante control process 512 to complete. The amount of time to perform the settlement may vary with each interval. Once energy service operation 514 is completed, the ex-post settlement is processed using measurements taken during Interval 1. While timeline 500 shows the ex-post step taking about 5 minutes, in practice it may be completed more quickly, as it does not rely on iterations between all layers. During the course of control interval 510, the ex-ante control process 522 of control interval 520 is performed in advance of energy service operation 524 which occurs immediately following energy service operation 512, from 10:15 to 10:30. In practice, the interval demarcations are invisible to the electrical network itself. The interleaved nature of the control processes allows power to flow continuously.

FIG. 6 illustrates another exemplary embodiment of the present disclosure. In this embodiment, the first layer controller 100 is an independent system operator (ISO) controller and/or a regional transmission operator (RTO) controller. The ISO and/or the RTO may operate a wholesale energy services market for large suppliers and consumers.

In this embodiment, the second layer controllers 1100-1300 are the distribution system controllers and the third layer controllers are the subnetwork controllers 1110-1330. Each of the third layer controllers is configured to control at least one third layer entity, i.e. subnetworks in the present embodiment. In other words, the hierarchy disclosed in this embodiment illustrated in FIG. 6 is shifted one layer up compared to the embodiment illustrated in FIGS. 1 and 2 so that, e.g., the first layer controller in the embodiment illustrated in FIGS. 1 and 2 is a distribution system controller but the distribution system controllers are second layer controllers in the embodiment illustrated in FIG. 6. Thus, it is understood by the skilled person that also embodiments with four or more layer are encompassed by the present disclosure.

A number of non-limiting exemplary embodiments shall now be further described.

An exemplary embodiment is a method for controlling operation of an electrical power network including a hierarchy of control layers. The method comprises providing a first layer controller at a first layer, the first layer controller being configured to couple the electrical power network to a higher layer electrical power transmission grid; providing second layer controllers at a second layer; and

providing third layer controllers at a third layer, each of the third layer controllers being configured to control at least one third layer entity, the first layer controller and the second layer controllers are configured to bi-directionally communicate which each other, and the second layer controllers and the third layer controllers are configured to bi-directionally communicate which each other, and each of the second layer controllers are configured to control a respective subnetwork comprising at least one of the third layer controllers and the respective at least one third layer entity. The method comprises determining a service control variable for controlling operation of the electrical power network, the determining comprising:

(a) determining and transmitting to the first layer controller by the second layer controllers aggregate energy service forecasts for their respective subnetworks determined based upon third layer entity energy service forecasts provided by the respective at least one third layer controller in each subnetwork;

(b) determining and transmitting to each of the second layer controllers by the first layer controller respective second layer controller-specific energy service forecasts determined in response to the aggregate energy service forecasts and a power flow optimization for the electrical power network, and

(c) determining and transmitting to the respective at least one third layer controller by the second layer controllers respective third layer controller-specific energy service forecasts and energy service requests determined in response to the respective second layer controller-specific energy service forecasts; and

in response to transmission of the third layer controller-specific energy service forecasts and energy service requests, receiving at the second layer at least a portion of the energy services requested by the third layer controllers and receiving at the first layer at least a portion of the energy services requested by the second layer controllers.

Various embodiments may preferably implement the following features:

Preferably the energy service forecast comprises energy service prices. Preferably the energy service forecast comprises energy service demand. Preferably the energy service forecast comprises energy service supply.

Preferably the method comprises before step (a):

(a0) determining and transmitting to the first layer controller by the second layer controllers initial aggregate energy service forecasts for their respective subnetworks based upon initial third layer entity energy service forecasts provided by the respective at least one third layer controller in each subnetwork;

(b0) determining and transmitting to each of the second layer controllers by the first layer controller an initial network-wide energy service forecast determined in response to the initial aggregate energy service forecasts and without use of a power flow optimization; and

(c0) determining and transmitting to the respective at least one third layer controller by the second layer controllers initial third layer controller-specific energy service forecasts determined in response to the initial network-wide energy service forecast.

Preferably the electrical power network is an electrical power distribution network. Preferably the first layer controller is a distribution system controller. Preferably the second layer controllers are subnetwork controllers, the third layer controllers are distributed energy resource-, DER-, controllers and the third layer entities are distributed energy resources. Preferably the first layer controller is an independent system operator controller and/or a regional transmission operator controller, the second layer controllers are distribution system controllers, the third layer controllers are subnetwork controllers and the third layer entities are respective subnetworks.

Preferably steps (a) to (c) are iteratively repeated and one or more iteration stopping criteria evaluations are performed including at least an evaluation of a limit of the number of iterations or the total time of iteration.

Preferably the one or more iteration stopping criteria evaluations include a convergence evaluation of one or more updated third layer controller-specific energy service forecasts.

Preferably the method comprises performing a control process after receiving at the first layer at least a portion of the energy services requested by the second layer controllers.

Preferably the control process comprises operating the first layer controller to compute a set of actual second layer-specific energy service forecasts in response to actual measurements of the energy services provided under control of the second layer controllers.

Preferably the control process comprises operating the second layer controllers to compute a plurality of sets of actual third layer controller-specific energy service forecasts in response to actual measurements of the energy services provided under control of the third layer controllers and the respective actual second layer-specific energy service forecasts.

Preferably the power flow optimization for the electrical power network is limited to an optimization of power flow in layers of the electrical power network between and including the first layer and the second layer.

Preferably the power flow optimization for the distribution network excludes any optimization of portions of the electrical power network between the second and the third layer.

An exemplary embodiment is a system for controlling operation of an electrical power network (100) including a hierarchy of control layers. The system comprises a first layer controller at a first layer, the first layer controller being configured to couple the electrical power network to a higher layer electrical power transmission grid; second layer controllers at a second layer; and third layer controllers at a third layer, each of the third layer controllers being configured to control at least one third layer entity, the first layer controller and the second layer controllers are configured to bi-directionally communicate which each other, and the second layer controllers and the third layer controllers are configured to bi-directionally communicate which each other, and each of the second layer controllers are configured to control a respective subnetwork comprising at least one of the third layer controllers and the respective at least one third layer entity. The system is configured to determine a service control variable for controlling operation of an electrical power network in which:

the second layer controllers are configured to (a) determine and transmit to the first layer controller aggregate energy service forecasts for their respective subnetworks determined based upon third layer entity energy service forecasts provided by the respective at least one third layer controller in each subnetwork; the first layer controller is configured to (b) determine and transmit to each of the second layer controllers respective second layer controller-specific energy service forecasts determined in response to the aggregate energy service forecasts and a power flow optimization for the electrical power network, and the second layer controllers are configured to (c) determine and transmit to the respective at least one third layer controller respective third layer controller-specific energy service forecasts and energy service requests determined in response to the respective second layer controller-specific energy service forecasts; and the second layer being configured to, in response to transmission of the third layer controller-specific energy service forecasts and energy service requests, receive at least a portion of the energy services requested by the third layer controllers, and

the first layer being configured to receive at least a portion of the energy services requested by the second layer controllers.

Various embodiments may preferably implement the following features:

Preferably the energy service forecast comprises energy service prices. Preferably the energy service forecast comprises energy service demand. Preferably the energy service forecast comprises energy service supply.

Preferably the second layer controllers are configured to determine and transmit to the first layer controller initial aggregate energy service forecasts for their respective subnetworks based upon initial third layer entity energy service forecasts provided by the respective at least one third layer controller in each subnetwork; the first layer controller is configured to determine and transmit to each of the second layer controllers an initial network-wide energy service forecast determined in response to the initial aggregate energy service forecasts and without use of a power flow optimization; and the second layer controllers are configured to determine and transmit to the respective at least one third layer controller initial third layer controller-specific energy service forecasts determined in response to the initial network-wide energy service forecast.

Preferably the electrical power network is an electrical power distribution network. Preferably the first layer controller is a distribution system controller. Preferably the second layer controllers are subnetwork controllers, the third layer controllers are distributed energy resource-, DER-, controllers and the third layer entities are distributed energy resources. Preferably the first layer controller is an independent system operator controller and/or a regional transmission operator controller, the second layer controllers are distribution system controllers, the third layer controllers are subnetwork controllers and the third layer entities are respective subnetworks.

Preferably the first layer controller and the second layer controllers are configured to repeat actions (a), (b), and (c) iteratively and the second layer controllers are configured to perform one or more iteration stopping criteria evaluations including at least an evaluation of a limit of the number of iterations or the total time of iteration.

Preferably the one or more iteration stopping criteria evaluations include a convergence evaluation of one or more updated third layer controller-specific energy service forecasts.

Preferably the system is configured to perform a control process after receiving at the first layer at least a portion of the energy services requested by the second layer controllers.

Preferably the first layer controller is configured to compute a set of actual second layer-specific energy service forecasts in response to actual measurements of the energy services provided under control of the second layer controllers.

Preferably the second layer controllers are configured to compute a plurality of sets of actual third layer controller-specific energy service forecasts in response to actual measurements of the energy services provided under control of the third layer controllers and the respective actual second layer-specific energy service forecasts.

Preferably the power flow optimization for the electrical power network is limited to an optimization of power flow in layers of the electrical power network between and including the first layer and the second layer.

Preferably the power flow optimization for the distribution network excludes any optimization of portions of the electrical power network between the second and the third layer.

Another exemplary embodiment is a method for controlling operation of an electrical power distribution network (distribution network) including a plurality of distributed energy resources (DERs) comprising: providing a distribution system controller at a transmission substation which couples the electrical power distribution network to an electrical power transmission grid; providing a plurality of subsystem controllers at a respective plurality of distribution substations serviced by the transmission substation and servicing a respective plurality of subnetworks of the distribution network, each of the subsystem controllers configured to bi-directionally communicate with the distribution system controller and to bidirectionally communicate with a respective plurality of distributed energy resource controllers (DER controllers), each of the DER controllers configured to control operation of one or more of the plurality of DERs, one or more of the DER controllers being configured to control operation of two or more DERs which are located in different subnetworks of the distribution network; in a first control process iteration performing an ex-ante energy service control variable simulation in which (a) the subnetwork controllers determine and transmit to the distribution network controller initial aggregate energy service price forecasts for their respective subnetworks based upon initial DER energy service price forecasts provided by the respective plurality of DER controllers in each subnetwork, (b) the distribution network controller determines and transmits to each of the subnetwork controllers an initial network-wide energy service price determined in response to the initial aggregate energy service price forecasts and without use of a power flow optimization, and (c) the subnetwork controllers determine and transmit to their respective DER controllers initial DER controller-specific energy service prices determined in response to the initial network-wide energy service price; in a second control process iteration after the first iteration performing an ex-ante energy service control variable determination and energy service request operation in which (a) the subnetwork controllers determine and transmit to the distribution network controller updated aggregate energy service prices for their respective subnetworks determined based upon updated DER energy service prices provided by the respective plurality of DER controllers in each subnetwork, (b) the distribution network controller determines and transmits to each of the subnetwork controllers respective subnetwork controller-specific energy service prices determined in response to the updated aggregate energy service prices and a power flow optimization for the distribution network, and (c) the subnetwork controllers determine and transmit to their respective DER controllers respective updated DER controller-specific energy service prices and energy service requests determined in response to the respective subnetwork controller-specific energy service prices; and in response to transmission of the DER controller-specific energy service prices and energy service requests, receiving at the distribution substations at least a portion of the energy services requested of the DER controllers and receiving at the transmission substation at least a portion of the energy services requested of the subsystem controllers.

Various embodiments may preferably implement the following features:

Preferably, the method of the first exemplary embodiment comprises, at the end of the second control process iteration one or more iteration stopping criteria evaluations are performed including at least an evaluation of a limit of the number of iterations or the total time of iteration. Preferably, the one or more iteration stopping criteria evaluations include a convergence evaluation of one or more updated DER controller-specific energy service prices. Certain forms comprise performing an ex-post control process after receiving at the transmission substation at least a portion of the energy services requested of the subsystem controllers. In certain forms, the ex-post control process comprises operating the distribution network controller to compute a set of actual substation-specific energy service prices in response to actual measurements of the energy services provided by the distribution substations under control of the subsystem controllers. Preferably, the ex-post control process comprises operating the substation controllers to compute a plurality of sets of actual DER-specific energy service prices in response to actual measurements of the energy services provided by the DERs under control of the DER controllers and the respective actual substation-specific energy service prices. In certain forms, the initial DER energy service price forecasts include respective DER energy service prices and corresponding DER linearized cost functions indicating the variation of the respective DER energy service forecast as a function of price, and the initial aggregate energy service price forecasts include an energy service price and a corresponding aggregate linearized cost function indicating the variation of the aggregate energy service forecast as a function of price. Preferably, the ex-ante energy service control variables include a real power price, a reactive power price, and a reserve capacity price. Preferably, the power flow optimization for the distribution network is limited to an optimization of power flow in layers of the distribution network between and including the transmission substation and the plurality of distribution substations. Preferably, the power flow optimization for the distribution network excludes any optimization of portions of the distribution network between distribution substations and the DERs.

Another exemplary embodiment is a system for controlling operation of an electrical power distribution network (distribution network) including a plurality of distributed energy resources (DERs), the system comprising: a distribution system controller operatively coupled with a transmission substation which couples the electrical power distribution network to an electrical power transmission grid; a plurality of subsystem controllers operatively coupled with a respective plurality of distribution substations serviced by the transmission substation and servicing a respective plurality of subnetworks of the distribution network, each of the subsystem controllers configured to bi-directionally communicate with the distribution system controller and to bi-directionally communicate with a respective plurality of distributed energy resource controllers (DER controllers), each of the DER controllers configured to control operation of one or more of the plurality of DERs, one or more of the DER controllers being configured to control operation of two or more DERs which are located in different subnetworks of the distribution network; the distribution system controller and the plurality of subsystem controllers being configured to perform an ex-ante energy service control variable simulation in which (a) the subnetwork controllers determine and transmit to the distribution network controller initial aggregate energy service price forecasts for their respective subnetworks based upon initial DER energy service price forecasts provided by the respective plurality of DER controllers in each subnetwork, (b) the distribution network controller determines and transmits to each of the subnetwork controllers an initial network-wide energy service price determined in response to the initial aggregate energy service price forecasts and without use of a power flow optimization, and (c) the subnetwork controllers determine and transmit to their respective DER controllers initial DER controller-specific energy service prices determined in response to the initial network-wide energy service price; the distribution system controller and the plurality of subsystem controllers being configured to perform an ex-ante energy service control variable determination and energy service request operation in which (a) the subnetwork controllers determine and transmit to the distribution network controller updated aggregate energy service prices for their respective subnetworks determined based upon updated DER energy service prices provided by the respective plurality of DER controllers in each subnetwork, (b) the distribution network controller determines and transmits to each of the subnetwork controllers respective subnetwork controller-specific energy service prices determined in response to the updated aggregate energy service prices and a power flow optimization for the distribution network, and (c) the subnetwork controllers determine and transmit to their respective DER controllers respective updated DER controller-specific energy service prices and energy service requests determined in response to the respective subnetwork controller-specific energy service prices; the distribution substations being configured to receive at least a portion of the energy services requested by the DER controllers; and the transmission substation being configured to receive at least a portion of the energy services requested by the subsystem controllers.

Various embodiments may preferably implement the following features:

Preferably of the second exemplary embodiment comprises the subnetwork controllers are configured to evaluate one or more iteration stopping criteria including at least an evaluation of a limit of the number of iterations or the total time of iteration. Preferably, the one or more iteration stopping criteria evaluations include a convergence evaluation of one or more updated DER controller-specific energy service prices. Preferably, the distribution system controller and the plurality of subsystem controllers are configured to perform an ex-post control process after receiving at the transmission substation at least a portion of the energy services requested of the subsystem controllers. Preferably, the distribution system controller and the plurality of subsystem controllers are configured to perform the ex-post control process comprises by operating the distribution network controller to compute a set of actual substation-specific energy service prices in response to actual measurements of the energy services provided by the distribution substations under control of the subsystem controllers. In certain forms, the distribution system controller and the plurality of subsystem controllers are configured to perform the ex post control process by operating the substation controllers to compute a plurality of sets of actual DER-specific energy service prices in response to actual measurements of the energy services provided by the DERs under control of the DER controllers and the respective actual substation-specific energy service prices. Preferably, the initial DER energy service price forecasts include respective DER energy service prices and corresponding DER linearized cost functions indicating the variation of the respective DER energy service forecast as a function of price, and the initial aggregate energy service price forecasts include an energy service price and a corresponding aggregate linearized cost function indicating the variation of the aggregate energy service forecast as a function of price. In certain forms, the ex-ante energy service control variables include one or more prices for real power, reactive power, and reserve capacity. Preferably, the power flow optimization for the distribution network is limited to an optimization of power flow in layers of the distribution network between and including the transmission substation and the plurality of distribution substations. Preferably, the power flow optimization for the distribution network excludes any optimization of portions of the distribution network between distribution substations and the DERs.

While illustrative embodiments of the disclosure have been illustrated and described in detail in the drawings and foregoing description, the same is to be considered as illustrative and not restrictive in character, it being understood that only certain exemplary embodiments have been shown and described and that all changes and modifications that come within the spirit of the claimed inventions are desired to be protected. It should be understood that while the use of words such as preferable, preferably, preferred or more preferred utilized in the description above indicates that the feature so described may be more desirable, it nonetheless may not be necessary and embodiments lacking the same may be contemplated as within the scope of the invention, the scope being defined by the claims that follow. In reading the claims, it is intended that when words such as “a,” “an,” “at least one,” or “at least one portion” are used there is no intention to limit the claim to only one item unless specifically stated to the contrary in the claim. When the language “at least a portion” and/or “a portion” is used the item can include a portion and/or the entire item unless specifically stated to the contrary. 

1-22. (canceled)
 23. A method for controlling operation of an electrical power network including a hierarchy of control layers, the method comprising: providing a first layer controller at a first layer, the first layer controller being configured to couple the electrical power network to a higher layer electrical power transmission grid; providing second layer controllers at a second layer; providing third layer controllers at a third layer, each of the third layer controllers being configured to control at least one third layer entity, the first layer controller and the second layer controllers are configured to bi-directionally communicate which each other, and the second layer controllers and the third layer controllers are configured to bi-directionally communicate which each other, and each of the second layer controllers are configured to control a respective subnetwork comprising at least one of the third layer controllers and the respective at least one third layer entity; determining a service control variable for controlling operation of the electrical power network, the determining comprising: (a) determining and transmitting to the first layer controller by the second layer controllers aggregate energy service forecasts for their respective subnetworks determined based upon third layer entity energy service forecasts provided by the respective at least one third layer controller in each subnetwork, (b) determining and transmitting to each of the second layer controllers by the first layer controller respective second layer controller -specific energy service forecasts determined in response to the aggregate energy service forecasts and a power flow optimization for the electrical power network, and (c) determining and transmitting to the respective at least one third layer controller by the second layer controllers respective third layer controller-specific energy service forecasts and energy service requests determined in response to the respective second layer controller-specific energy service forecasts; and in response to transmission of the third layer controller-specific energy service forecasts and energy service requests, receiving at the second layer at least a portion of the energy services requested by the third layer controllers and receiving at the first layer at least a portion of the energy services requested by the second layer controllers.
 24. The method of claim 23, comprising before step (a): (a0) determining and transmitting to the first layer controller by the second layer controllers initial aggregate energy service forecasts for their respective subnetworks based upon initial third layer entity energy service forecasts provided by the respective at least one third layer controller in each subnetwork; (b0) determining and transmitting to each of the second layer controllers by the first layer controller an initial network-wide energy service forecast determined in response to the initial aggregate energy service forecasts and without use of a power flow optimization; and (c0) determining and transmitting to the respective at least one third layer controller by the second layer controllers initial third layer controller-specific energy service forecasts determined in response to the initial network-wide energy service forecast.
 25. The method of claim 23, wherein the electrical power network is an electrical power distribution network, the first layer controller is a distribution system controller, the second layer controllers are subnetwork controllers, the third layer controllers are distributed energy resource-, DER-, controllers and the third layer entities are distributed energy resources.
 26. The method of claim 23, wherein the first layer controller is an independent system operator controller and/or a regional transmission operator controller, the second layer controllers are distribution system controllers, the third layer controllers are subnetwork controllers and the third layer entities are respective subnetworks.
 27. The method of claim 23, wherein steps (a) to (c) are iteratively repeated and one or more iteration stopping criteria evaluations are performed including at least an evaluation of a limit of a number of iterations or a total time of iteration.
 28. The method of claim 27, wherein the one or more iteration stopping criteria evaluations include a convergence evaluation of one or more updated third layer controller-specific energy service forecasts.
 29. The method of claim 23, comprising performing a control process after receiving at the first layer at least a portion of the energy services requested by the second layer controllers.
 30. The method of claim 29, wherein the control process comprises operating the first layer controller to compute a set of actual second layer-specific energy service forecasts in response to actual measurements of the energy services provided under control of the second layer controllers.
 31. The method of claim 30, wherein the control process comprises operating the second layer controllers to compute a plurality of sets of actual third layer controller-specific energy service forecasts in response to actual measurements of the energy services provided under control of the third layer controllers and the respective actual second layer-specific energy service forecasts.
 32. The method of claim 23, wherein the power flow optimization for the electrical power network is limited to an optimization of power flow in layers of the electrical power network between and including the first layer and the second layer.
 33. The method of claim 23, wherein the power flow optimization for the electrical power network excludes any optimization of portions of the electrical power network between the second and the third layer.
 34. A system for controlling operation of an electrical power network including a hierarchy of control layers, the system comprising: a first layer controller at a first layer, the first layer controller being configured to couple the electrical power network to a higher layer electrical power transmission grid; second layer controllers at a second layer; and third layer controllers at a third layer, each of the third layer controllers being configured to control at least one third layer entity, the first layer controller and the second layer controllers are configured to bi-directionally communicate which each other, and the second layer controllers and the third layer controllers are configured to bi-directionally communicate which each other, and each of the second layer controllers are configured to control a respective subnetwork comprising at least one of the third layer controllers and the respective at least one third layer entity; the system being configured to determine a service control variable for controlling operation of the electrical power network in which: the second layer controllers are configured to (a) determine and transmit to the first layer controller aggregate energy service forecasts for their respective subnetworks determined based upon third layer entity energy service forecasts provided by the respective at least one third layer controller in each subnetwork, the first layer controller is configured to (b) determine and transmit to each of the second layer controllers respective second layer controller-specific energy service forecasts determined in response to the aggregate energy service forecasts and a power flow optimization for the electrical power network, and the second layer controllers are configured to (c) determine and transmit to the respective at least one third layer controller respective third layer controller-specific energy service forecasts and energy service requests determined in response to the respective second layer controller-specific energy service forecasts; the second layer being configured to, in response to transmission of the third layer controller-specific energy service forecasts and energy service requests, receive at least a portion of the energy services requested by the third layer controllers; and the first layer being configured to receive at least a portion of the energy services requested by the second layer controllers.
 35. The system of claim 34, wherein: the second layer controllers are configured to determine and transmit to the first layer controller initial aggregate energy service forecasts for their respective subnetworks based upon initial third layer entity energy service forecasts provided by the respective at least one third layer controller in each subnetwork; the first layer controller is configured to determine and transmit to each of the second layer controllers an initial network-wide energy service forecast determined in response to the initial aggregate energy service forecasts and without use of a power flow optimization; and the second layer controllers are configured to determine and transmit to the respective at least one third layer controller initial third layer controller-specific energy service forecasts determined in response to the initial network-wide energy service forecast.
 36. The system of claim 34, wherein the electrical power network is an electrical power distribution network, the first layer controller is a distribution system controller, the second layer controllers are subnetwork controllers, the third layer controllers are distributed energy resource-, DER-, controllers and the third layer entities are distributed energy resources.
 37. The system of claim 34, wherein the first layer controller is an independent system operator controller and/or a regional transmission operator controller, the second layer controllers are distribution system controllers, the third layer controllers are subnetwork controllers and the third layer entities are respective subnetworks.
 38. The system of claim 34, wherein the first layer controller and the second layer controllers are configured to repeat actions (a), (b), and (c) iteratively and the second layer controllers are configured to perform one or more iteration stopping criteria evaluations including at least an evaluation of a limit of a number of iterations or a total time of iteration.
 39. The system of claim 38, wherein the one or more iteration stopping criteria evaluations include a convergence evaluation of one or more updated third layer controller-specific energy service forecasts.
 40. The system of claim 34, wherein the system is configured to perform a control process after receiving at the first layer at least a portion of the energy services requested by the second layer controllers.
 41. The system of claim 40, wherein the first layer controller is configured to compute a set of actual second layer-specific energy service forecasts in response to actual measurements of the energy services provided under control of the second layer controllers.
 42. The system of claim 41, wherein the second layer controllers are configured to compute a plurality of sets of actual third layer controller-specific energy service forecasts in response to actual measurements of the energy services provided under control of the third layer controllers and the respective actual second layer-specific energy service forecasts.
 43. The system of claim 34, wherein the power flow optimization for the electrical power network is limited to an optimization of power flow in layers of the electrical power network between and including the first layer and the second layer.
 44. The system of claim 34, wherein the power flow optimization for the electrical power network excludes any optimization of portions of the electrical power network between the second and the third layer. 